US20100326664A1 - Running Tool That Prevents Seal Test - Google Patents
Running Tool That Prevents Seal Test Download PDFInfo
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- US20100326664A1 US20100326664A1 US12/490,874 US49087409A US2010326664A1 US 20100326664 A1 US20100326664 A1 US 20100326664A1 US 49087409 A US49087409 A US 49087409A US 2010326664 A1 US2010326664 A1 US 2010326664A1
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- stem
- inner body
- piston
- running tool
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/04—Casing heads; Suspending casings or tubings in well heads
Definitions
- This technique relates in general to tools for running casing hangers and in subsea wells, and in particular to a running tool that prevents a seal test when the seal is not properly set.
- a subsea well of the type concerned herein will have a wellhead supported on the subsea floor.
- One or more strings of casing will be lowered into the wellhead from the surface, each supported on a casing hanger.
- the casing hanger is a tubular member that is secured to the threaded upper end of the string of casing.
- the casing hanger lands on a landing shoulder in the wellhead, or on a previously installed casing hanger having larger diameter casing.
- Cement is pumped down the string of casing to flow back up the annulus around the string of casing.
- a packoff is positioned between the wellhead bore and an upper portion of the casing hanger. This seals the casing hanger annulus.
- Casing hanger running tools perform many functions such as running and landing casing strings, cementing strings into place, and installing and testing packoffs. Once a packoff is set, it is often tested by applying fluid pressure to an upper side of the packoff. If the packoff has not been properly set, fluid pressure may leak past the annulus packoff, causing the casing to collapse.
- the following technique may solve one or more of these problems.
- a running tool sets a casing hanger packoff and allows the packoff to be tested, but only if the packoff has been properly set.
- the running tool is comprised of an inner body, a piston, and a stem.
- the inner body substantially surrounds and is connected to the stem of the running tool so that rotation of the stem relative to the inner body will cause the stem to move longitudinally.
- the piston substantially surrounds the inner body and the stem and is connected to the stem so that the piston and the stem rotate and move longitudinally in unison.
- a port extends through the inner body from an exterior surface thereof and passes into a chamber defined by the area between the stem, the piston, and the inner body.
- the stem has a raised profile on a portion of its outer surface.
- the inner body has a seal positioned on its interior surface that seals against the raised surface portion of the stem when the packoff is properly set and the packoff is tested, thereby prohibiting fluid pressure from passing from the chamber and into the passage between the inner body and the stem.
- a test slot is located in and extends through the exterior surface of the inner body.
- An inwardly biased limit pin is carried by the piston and is adapted to fully engage the test slot when the packoff is properly set. Downward longitudinal movement of the stem and piston relative to the inner body sufficient to properly set the packoff allows the limit pin to fully engage the test slot and reach a set position. Downward longitudinal movement of the stem and piston relative to the inner body insufficient to properly set the packoff allows the limit pin to only partially engage the test slot and reach a safe position.
- the stem and piston move longitudinally upward relative to the inner body. If the limit pin has fully engaged the slot, the limit pin will move from the set position to a test position whereby the seal on the inner surface of the inner body seals against the raised profile portion of the stem, allowing fluid pressure to reach the packoff, thereby testing it. If the limit pin has only partially engaged the slot, the limit pin will maintain the safe position whereby the seal on the inner surface of the inner body will not seal against the raised profile portion of the stem, allowing fluid pressure to pass through the port, into the chamber, and through the passage between the stem and the inner body before flowing back up the string of drill pipe.
- FIG. 1 is a sectional view of a running tool constructed in accordance with the present technique with the piston cocked and the engagement element retracted.
- FIG. 2 is a sectional view of the running tool of FIG. 1 in the running position with the engagement element engaged.
- FIG. 3 is a sectional view of the running tool of FIG. 1 with the piston and stem released from the inner body.
- FIG. 4 is an enlarged view of the limit pin and test slot portions of the running tool of FIG. 3 .
- FIG. 5 is an enlarged view of the stem and inner body seal portions of the running tool of FIG. 3 .
- FIG. 6 is a sectional view of the running tool of FIG. 1 in the landing position.
- FIG. 7 is an enlarged view of the limit pin and test slot portions of the running tool of FIG. 6 .
- FIG. 8 is an enlarged view of the stem and inner body seal portions of the running tool of FIG. 6 .
- FIG. 9 is a sectional view of the running tool of FIG. 1 in the set position.
- FIG. 10 is an enlarged view of the limit pin and test slot portions of the running tool of FIG. 9 .
- FIG. 11 is a sectional view of the running tool of FIG. 1 in the test position.
- FIG. 12 is an enlarged view of the limit pin and test slot portions of the running tool of FIG. 11 .
- FIG. 13 is an enlarged view of the stem and inner body seal portions of the running tool of FIG. 11 .
- FIG. 14 is a sectional view of the running tool of FIG. 1 in the unlocked position with the engagement element disengaged.
- FIG. 15 is a sectional view of the running tool of FIG. 1 in a partially set position.
- FIG. 16 is an enlarged view of the limit pin and test slot portions of the running tool of FIG. 15 .
- FIG. 17 is a sectional view of the running tool of FIG. 1 in a safe position.
- FIG. 18 is an enlarged view of the limit pin and test slot portions of the running tool of FIG. 17 .
- FIG. 19 is an enlarged view of the stem and inner body seal portions of the running tool of FIG. 17 .
- the running tool 31 is comprised of a stem 33 .
- Stem 33 is a tubular member with an axial passage 35 extending therethrough.
- Stem 33 connects on its upper end to a string of drill pipe (not shown).
- Stem 33 has a first raised profile 37 on its outer surface.
- a second raised profile 39 is positioned on the outer surface of stem 33 , an increment below the first raised profile 37 .
- the portions of stem 33 where first raised profiles 37 , 39 are positioned have a greater diameter than the portions of the stem 33 positioned above and below the profiles 37 , 39 .
- a lower portion of the stem 33 has threads 41 in its outer surface.
- Running tool 31 has an inner body 43 that surrounds stem 33 , as stem 33 extends axially through the inner body 43 .
- Inner body 43 has an upper body portion 45 and a lower body portion 47 .
- a seal 49 is positioned between the inner surface of the upper body portion 45 of inner body 43 and stem 33 . Seal 49 acts to seal between the inner body 43 and the stem 33 when the seal 49 is engaged with either of the raised profiles 37 , 39 on the outer surface of stem 33 .
- Inner body 43 has a fluid port 51 positioned in and extending diagonally inward from its exterior surface near lower body portion 47 . Fluid port 51 then extends axially upward from the lower body portion 47 through the upper body portion 45 of inner body 43 . Fluid port 51 allows fluid communication between the exterior and interior of the inner body 43 when the seal 49 is not engaged with raised profiles 37 , 39 on stem 33 .
- the lower body portion 47 of inner body 43 is connected to a bearing cap 53 .
- the bearing cap 53 has threads 55 along its inner surface that are engaged with threads 41 on the outer surface of stem 33 .
- the lower portion 47 of inner body 43 and bearing cap 53 house an engaging element 57 .
- engaging element 57 is a set of dogs having a smooth inner surface and a contoured outer surface.
- the contoured outer surface is adapted to engage a complimentary contoured surface 59 on the inner surface of a casing hanger 61 when the engagement element 57 is engaged with the casing hanger 61 .
- a string of casing is attached to the lower end of casing hanger 61 .
- the lower body portion 47 of inner body 43 has an inner recess with threads 63 along its inner surface.
- a cam 65 is positioned between the stem 33 and the inner recess of inner body 43 .
- Cam 65 has threads 67 on its outer surface that are in engagement with the threads 63 on the surface of the inner recess of lower body portion 47 of inner body 43 .
- Cam 65 and stem 33 are connected to one another such that cam 65 and stem 33 rotate in unison, but cam 65 may move axially relative to inner body 43 , independent from stem 33 .
- cam 65 and stem 33 may be connected to one another by means of anti-rotation keys.
- a test slot 71 is located in and extends radially inward through the exterior surface of the inner body 43 .
- a restrictor 75 divides slot 71 into an inner pocket portion and an outer pocket portion, forming a downward facing shoulder 81 between the two. The diameter of slot 71 is greater below the restrictor 75 than above.
- An outer body or piston 83 surrounds stem 33 and substantial portions of the inner body 43 .
- Piston 83 is connected to stem 33 such that the two rotate and move in unison.
- a piston chamber 85 is formed between an upper surface of upper body portion 45 of inner body 43 , inner surface portions of piston 83 , and outer surface portions of stem 33 .
- Piston 83 is initially in an upper position relative to inner body 43 , meaning that the area of piston chamber 85 is at its largest possible value, allowing for piston 83 to be driven downward.
- a limit pin 89 is connected to the outer surface of the outer body or piston 83 .
- Limit pin 89 is connected to piston 83 by way of an inwardly biased spring 95 that forces limit pin 89 inwards.
- Limit pin 89 rides in an aperture 97 located in and extending through piston 83 .
- Limit pin 89 is initially in contact with the outer surface of inner body 43 .
- Limit pin 89 is adapted to engage test slot 71 and enter into the lower portion of the slot 71 with the larger diameter when the piston 83 moves axially relative to the inner body a desired distance.
- a setting sleeve 101 is connected to the lower end of piston 83 .
- Setting sleeve 101 carries a packoff seal 103 which is positioned along the lower end portion of setting sleeve 101 .
- Packoff seal 103 will act to seal the casing hanger 61 to a high pressure housing when properly set. While piston 83 is in the upper position, packoff seal 103 is spaced above casing hanger 61 .
- An elastomeric seal 105 is located on the outer surface of the running tool 31 between piston 83 and setting sleeve 101 and expands radially when weight is applied downward on it, thereby sealing between the running tool 31 and a high pressure housing.
- the running tool 31 is initially positioned such that it extends axially through a casing hanger 61 .
- the piston 83 is in an upper position, and the raised profiles 37 , 39 on stem 33 are not in contact with the seal 49 on the inner surface of inner body 43 .
- Casing hanger packoff seal 103 is carried by setting sleeve 101 which is connected to piston 83 .
- the running tool 31 is lowered into the casing hanger 61 until the outer surface of inner body 43 and bearing cap 53 of running tool 31 slidingly engage the inner surface of casing hanger 61 .
- the stem 33 is rotated four revolutions. As stem 33 rotates, a portion of it unthreads from bearing cap 53 and stem 33 and piston 83 move longitudinally downward relative to inner body 43 . As the stem 33 and piston 83 move longitudinally downward relative to inner body 43 , the limit pin 89 captured in aperture 97 on piston 83 also moves longitudinally downward relative to inner body 43 . As the stem 33 is rotated relative to the inner body 43 , cam 65 rotates in unison and simultaneously unthreads from inner body 43 and moves longitudinally downward relative to inner body 43 .
- a shoulder 107 on the outer surface of the cam 65 makes contact with the engaging element 57 , forcing it radially outward and in engaging contact with profile 59 on the inner surface of casing hanger 61 , thereby locking inner body 43 to casing hanger 61 .
- the seal 49 on the inner surface of inner body 43 and raised profiles 37 , 39 on the outer surface of stem 33 also move relative to one another.
- stem 33 is then rotated four additional revolutions in the same direction.
- the stem 33 completely unthreads from bearing cap 53 , freeing stem 33 and piston 83 to move further longitudinally downward relative to inner body. 43 and casing hanger 61 .
- the limit pin 89 captured in aperture 97 on piston 83 also moves further longitudinally downward relative to inner body 43 ( FIG. 4 ).
- the seal 49 on the inner surface of inner body 43 and raised profiles 37 , 39 on the outer surface of stem 33 also move relative to one another. Seal 49 engages the first raised profile 37 on the outer surface of stem 33 ( FIG. 5 ).
- Restrictor 75 prevents limit pin 89 from fully entering slot 71 ( FIG. 7 ).
- the seal 49 on the inner surface of inner body 43 and raised profiles 37 , 39 on the outer surface of stem 33 also move relative to one another. Seal 49 on the inner surface of inner body 43 disengages from first raised profile 37 on the outer surface of stem 33 ( FIG. 8 ).
- drillpipe rams (not shown) or an annular blower preventer (not shown) are closed and fluid pressure is applied down the annulus.
- Elastomeric seal 105 seals between running tool 31 and high pressure housing 111 , allowing the pressure above seal 105 to build until it forces stem 33 and piston 83 longitudinally downward relative to inner body 43 .
- the movement of piston 83 sets the packoff seal 103 between an outer portion of casing hanger 61 and the inner diameter of the subsea wellhead housing 111 .
- Piston 83 moves longitudinally downward relative to inner body 43 until piston chamber 85 ( FIG. 1 ) is eliminated and piston 83 and inner body 43 are in contact with one another.
- limit pin 89 captured in aperture 97 on piston 83 also moves further longitudinally downward relative to inner body 43 .
- limit pin 89 reaches the lower portion of test slot 71 and is no longer restricted by restrictor 75 .
- Limit pin 89 is forced further radially inward by spring 95 , fully entering slot 71 and reaching a “set” position ( FIG. 10 ).
- limit pin 89 travels upwards in slot 71 on the inner body 43 until limit pin 89 reaches the uppermost end of slot 71 reaching a “test” position ( FIG. 12 ).
- the seal 49 on the inner surface of inner body 43 and raised profiles 37 , 39 on the outer surface of stem 33 also move relative to one another. Seal 49 engages the first raised profile 37 on the outer surface of stem 33 ( FIG. 13 ). This position prohibits fluid communication from the exterior of inner body 43 to the interior of the inner body 43 , through fluid port 51 and chamber 85 .
- fluid pressure is applied down the annulus to the upper side of packoff seal 103 , thereby testing it.
- the stem 33 is then rotated four additional revolutions in the same direction.
- cam 65 moves longitudinally downward relative to inner body 43 .
- engaging element 57 is no longer forced outward by cam 65 , and moves radially inward, thereby unlocking the running tool 31 from the casing hanger 61 .
- Running tool 31 may then be removed from the wellbore and returned to the surface.
- packoff seal 103 if packoff seal 103 is not properly set, running tool 31 prevents the packoff 103 from being tested. For example, if debris and/or trash 113 is present in the shoulder area of hanger 61 , seal 103 may not properly set. As illustrated in FIG. 15 , pressure has been applied above elastomeric seal 105 to set packoff seal 103 , however, stem 33 and piston 83 did not move sufficiently longitudinally downward relative to inner body 43 to set packoff seal 103 . As illustrated in FIG. 17 , although limit pin 89 has moved radially inward and partially entered slot 71 , restrictor 75 has prevented limit pin 89 from fully entering test slot 71 . Since piston 83 did not move sufficiently longitudinally downward relative to inner body 43 to set packoff seal 103 , limit pin 89 also did not move sufficiently longitudinally downward relative to inner body 43 to fully enter test slot 71 .
- the running and testing sequence is continued and the stem 33 and piston 83 are pulled longitudinally upward relative to the inner body 43 with sufficient force to release the packoff seal 103 from the setting sleeve 101 .
- the weight is removed from elastomeric seal 105 and it moves radially inward, disengaging the inner surface of the wellhead housing 111 , thereby permitting fluid flow past the seal 105 .
- limit pin 89 travels upwards in slot 71 , restricted from moving radially inward by restrictor 75 on the inner body 43 .
- limit pin 89 reaches an upper end of slot 71 where it contacts downward facing shoulder 89 which prevents further upward movement of limit pin 89 ( FIG. 18 ). Because the limit pin did not fully enter slot 71 , limit pin 89 can not reach the uppermost end of slot 71 ( FIG. 12 ). This position is considered a “safe” position that will prevent a true packoff seal 103 test. ( FIG. 18 ).
- stem 33 and piston 83 can not move sufficiently longitudinally upward relative to inner body 43 for seal 49 to engage the first raised profile 37 on the outer surface of stem 33 ( FIG. 19 ).
- fluid may communicate from the exterior of inner body 43 through fluid port 51 , into chamber 85 , through the space between the interior of the inner body 43 and stem 33 , and back up the drill string.
- the technique has significant advantages.
- the running tool combines the limit pin and the test slot with the raised profile portion of the stem and the seal on the inner body to ensure that the packoff is not pressure tested unless the proper setting stroke is made by the running tool.
- the fluid port allows fluid to travel from the exterior of the running tool through the components and back up the drill string if the packoff has not been properly set, reducing the chance of pressure leaking past the packoff and collapsing the casing.
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Abstract
A running tool sets a casing hanger packoff and ensures that the packoff is not pressure tested unless the proper setting stroke was made by the running tool. The running tool has a stem, an inner body, and a piston. The inner body is connected to the stem so that rotation of the stem relative to the inner body will cause the stem to move longitudinally. The piston is connected to the stem so that the stem and piston rotate and move longitudinally in unison. A test slot is located in the outer surface of the inner body. A limit pin is connected to the piston and is adapted to engage the test slot when the piston moves longitudinally relative to the inner body. The stem has a raised profile on a portion of its exterior surface.
Description
- This technique relates in general to tools for running casing hangers and in subsea wells, and in particular to a running tool that prevents a seal test when the seal is not properly set.
- A subsea well of the type concerned herein will have a wellhead supported on the subsea floor. One or more strings of casing will be lowered into the wellhead from the surface, each supported on a casing hanger. The casing hanger is a tubular member that is secured to the threaded upper end of the string of casing. The casing hanger lands on a landing shoulder in the wellhead, or on a previously installed casing hanger having larger diameter casing. Cement is pumped down the string of casing to flow back up the annulus around the string of casing. Afterward, a packoff is positioned between the wellhead bore and an upper portion of the casing hanger. This seals the casing hanger annulus.
- Casing hanger running tools perform many functions such as running and landing casing strings, cementing strings into place, and installing and testing packoffs. Once a packoff is set, it is often tested by applying fluid pressure to an upper side of the packoff. If the packoff has not been properly set, fluid pressure may leak past the annulus packoff, causing the casing to collapse.
- A need exists for a technique that ensures that the packoff is pressure tested only when it has been properly set. The following technique may solve one or more of these problems.
- In an embodiment of the present technique, a running tool sets a casing hanger packoff and allows the packoff to be tested, but only if the packoff has been properly set. The running tool is comprised of an inner body, a piston, and a stem. The inner body substantially surrounds and is connected to the stem of the running tool so that rotation of the stem relative to the inner body will cause the stem to move longitudinally. The piston substantially surrounds the inner body and the stem and is connected to the stem so that the piston and the stem rotate and move longitudinally in unison.
- A port extends through the inner body from an exterior surface thereof and passes into a chamber defined by the area between the stem, the piston, and the inner body. The stem has a raised profile on a portion of its outer surface. The inner body has a seal positioned on its interior surface that seals against the raised surface portion of the stem when the packoff is properly set and the packoff is tested, thereby prohibiting fluid pressure from passing from the chamber and into the passage between the inner body and the stem. A test slot is located in and extends through the exterior surface of the inner body.
- An inwardly biased limit pin is carried by the piston and is adapted to fully engage the test slot when the packoff is properly set. Downward longitudinal movement of the stem and piston relative to the inner body sufficient to properly set the packoff allows the limit pin to fully engage the test slot and reach a set position. Downward longitudinal movement of the stem and piston relative to the inner body insufficient to properly set the packoff allows the limit pin to only partially engage the test slot and reach a safe position.
- When the packoff is to be tested, the stem and piston move longitudinally upward relative to the inner body. If the limit pin has fully engaged the slot, the limit pin will move from the set position to a test position whereby the seal on the inner surface of the inner body seals against the raised profile portion of the stem, allowing fluid pressure to reach the packoff, thereby testing it. If the limit pin has only partially engaged the slot, the limit pin will maintain the safe position whereby the seal on the inner surface of the inner body will not seal against the raised profile portion of the stem, allowing fluid pressure to pass through the port, into the chamber, and through the passage between the stem and the inner body before flowing back up the string of drill pipe.
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FIG. 1 is a sectional view of a running tool constructed in accordance with the present technique with the piston cocked and the engagement element retracted. -
FIG. 2 is a sectional view of the running tool ofFIG. 1 in the running position with the engagement element engaged. -
FIG. 3 is a sectional view of the running tool ofFIG. 1 with the piston and stem released from the inner body. -
FIG. 4 is an enlarged view of the limit pin and test slot portions of the running tool ofFIG. 3 . -
FIG. 5 is an enlarged view of the stem and inner body seal portions of the running tool ofFIG. 3 . -
FIG. 6 is a sectional view of the running tool ofFIG. 1 in the landing position. -
FIG. 7 is an enlarged view of the limit pin and test slot portions of the running tool ofFIG. 6 . -
FIG. 8 is an enlarged view of the stem and inner body seal portions of the running tool ofFIG. 6 . -
FIG. 9 is a sectional view of the running tool ofFIG. 1 in the set position. -
FIG. 10 is an enlarged view of the limit pin and test slot portions of the running tool ofFIG. 9 . -
FIG. 11 is a sectional view of the running tool ofFIG. 1 in the test position. -
FIG. 12 is an enlarged view of the limit pin and test slot portions of the running tool ofFIG. 11 . -
FIG. 13 is an enlarged view of the stem and inner body seal portions of the running tool ofFIG. 11 . -
FIG. 14 is a sectional view of the running tool ofFIG. 1 in the unlocked position with the engagement element disengaged. -
FIG. 15 is a sectional view of the running tool ofFIG. 1 in a partially set position. -
FIG. 16 is an enlarged view of the limit pin and test slot portions of the running tool ofFIG. 15 . -
FIG. 17 is a sectional view of the running tool ofFIG. 1 in a safe position. -
FIG. 18 is an enlarged view of the limit pin and test slot portions of the running tool ofFIG. 17 . -
FIG. 19 is an enlarged view of the stem and inner body seal portions of the running tool ofFIG. 17 . - Referring to
FIG. 1 , there is generally shown an embodiment for a runningtool 31 that is used to set and test a casing hanger packoff. The runningtool 31 is comprised of astem 33.Stem 33 is a tubular member with anaxial passage 35 extending therethrough.Stem 33 connects on its upper end to a string of drill pipe (not shown).Stem 33 has a first raisedprofile 37 on its outer surface. A second raisedprofile 39 is positioned on the outer surface ofstem 33, an increment below the first raisedprofile 37. The portions ofstem 33 where first raisedprofiles stem 33 positioned above and below theprofiles stem 33 hasthreads 41 in its outer surface. - Running
tool 31 has aninner body 43 that surroundsstem 33, asstem 33 extends axially through theinner body 43.Inner body 43 has anupper body portion 45 and alower body portion 47. Aseal 49 is positioned between the inner surface of theupper body portion 45 ofinner body 43 andstem 33.Seal 49 acts to seal between theinner body 43 and thestem 33 when theseal 49 is engaged with either of the raisedprofiles stem 33.Inner body 43 has afluid port 51 positioned in and extending diagonally inward from its exterior surface nearlower body portion 47.Fluid port 51 then extends axially upward from thelower body portion 47 through theupper body portion 45 ofinner body 43.Fluid port 51 allows fluid communication between the exterior and interior of theinner body 43 when theseal 49 is not engaged with raisedprofiles stem 33. - The
lower body portion 47 ofinner body 43 is connected to abearing cap 53. The bearingcap 53 hasthreads 55 along its inner surface that are engaged withthreads 41 on the outer surface ofstem 33. Thelower portion 47 ofinner body 43 andbearing cap 53 house an engagingelement 57. In this particular embodiment, engagingelement 57 is a set of dogs having a smooth inner surface and a contoured outer surface. The contoured outer surface is adapted to engage a complimentary contouredsurface 59 on the inner surface of acasing hanger 61 when theengagement element 57 is engaged with thecasing hanger 61. Although not shown, a string of casing is attached to the lower end ofcasing hanger 61. - The
lower body portion 47 ofinner body 43 has an inner recess withthreads 63 along its inner surface. Acam 65 is positioned between thestem 33 and the inner recess ofinner body 43.Cam 65 hasthreads 67 on its outer surface that are in engagement with thethreads 63 on the surface of the inner recess oflower body portion 47 ofinner body 43.Cam 65 and stem 33 are connected to one another such thatcam 65 and stem 33 rotate in unison, butcam 65 may move axially relative toinner body 43, independent fromstem 33. For example,cam 65 and stem 33 may be connected to one another by means of anti-rotation keys. - A
test slot 71 is located in and extends radially inward through the exterior surface of theinner body 43. A restrictor 75divides slot 71 into an inner pocket portion and an outer pocket portion, forming a downward facingshoulder 81 between the two. The diameter ofslot 71 is greater below the restrictor 75 than above. - An outer body or
piston 83 surroundsstem 33 and substantial portions of theinner body 43.Piston 83 is connected to stem 33 such that the two rotate and move in unison. Apiston chamber 85 is formed between an upper surface ofupper body portion 45 ofinner body 43, inner surface portions ofpiston 83, and outer surface portions ofstem 33.Piston 83 is initially in an upper position relative toinner body 43, meaning that the area ofpiston chamber 85 is at its largest possible value, allowing forpiston 83 to be driven downward. - A
limit pin 89 is connected to the outer surface of the outer body orpiston 83.Limit pin 89 is connected topiston 83 by way of an inwardlybiased spring 95 that forces limitpin 89 inwards.Limit pin 89 rides in anaperture 97 located in and extending throughpiston 83.Limit pin 89 is initially in contact with the outer surface ofinner body 43.Limit pin 89 is adapted to engagetest slot 71 and enter into the lower portion of theslot 71 with the larger diameter when thepiston 83 moves axially relative to the inner body a desired distance. - A setting
sleeve 101 is connected to the lower end ofpiston 83. Settingsleeve 101 carries apackoff seal 103 which is positioned along the lower end portion of settingsleeve 101.Packoff seal 103 will act to seal thecasing hanger 61 to a high pressure housing when properly set. Whilepiston 83 is in the upper position,packoff seal 103 is spaced above casinghanger 61. - An
elastomeric seal 105 is located on the outer surface of the runningtool 31 betweenpiston 83 and settingsleeve 101 and expands radially when weight is applied downward on it, thereby sealing between the runningtool 31 and a high pressure housing. - Referring to
FIG. 1 , in operation, the runningtool 31 is initially positioned such that it extends axially through acasing hanger 61. Thepiston 83 is in an upper position, and the raisedprofiles stem 33 are not in contact with theseal 49 on the inner surface ofinner body 43. Casinghanger packoff seal 103 is carried by settingsleeve 101 which is connected topiston 83. The runningtool 31 is lowered into thecasing hanger 61 until the outer surface ofinner body 43 andbearing cap 53 of runningtool 31 slidingly engage the inner surface ofcasing hanger 61. - Referring to
FIG. 2 , once runningtool 31 andcasing hanger 61 are in abutting contact with one another, thestem 33 is rotated four revolutions. Asstem 33 rotates, a portion of it unthreads from bearingcap 53 andstem 33 andpiston 83 move longitudinally downward relative toinner body 43. As thestem 33 andpiston 83 move longitudinally downward relative toinner body 43, thelimit pin 89 captured inaperture 97 onpiston 83 also moves longitudinally downward relative toinner body 43. As thestem 33 is rotated relative to theinner body 43,cam 65 rotates in unison and simultaneously unthreads frominner body 43 and moves longitudinally downward relative toinner body 43. Ashoulder 107 on the outer surface of thecam 65 makes contact with the engagingelement 57, forcing it radially outward and in engaging contact withprofile 59 on the inner surface ofcasing hanger 61, thereby lockinginner body 43 tocasing hanger 61. As thestem 33 moves longitudinally, theseal 49 on the inner surface ofinner body 43 and raisedprofiles stem 33 also move relative to one another. Once the runningtool 31 andcasing hanger 61 are locked to one another, the runningtool 31 andcasing hanger 61 are lowered down the riser into ahigh pressure housing 111 until thecasing hanger 61 comes to rest. - Referring to
FIG. 3 , stem 33 is then rotated four additional revolutions in the same direction. As thestem 33 is rotated relative to theinner body 43, thestem 33 completely unthreads from bearingcap 53, freeingstem 33 andpiston 83 to move further longitudinally downward relative to inner body.43 andcasing hanger 61. As thestem 33 andpiston 83 move further longitudinally downward relative toinner body 43, thelimit pin 89 captured inaperture 97 onpiston 83 also moves further longitudinally downward relative to inner body 43 (FIG. 4 ). As thestem 33 moves further longitudinally downward, theseal 49 on the inner surface ofinner body 43 and raisedprofiles stem 33 also move relative to one another.Seal 49 engages the first raisedprofile 37 on the outer surface of stem 33 (FIG. 5 ). - Referring to
FIG. 6 , weight is then applied downward on the string of drill pipe (not shown) and subsequently to thestem 33 andpiston 83. Asstem 33 andpiston 83 move further longitudinally downward relative toinner body 43, thepackoff seal 103 lands between thecasing hanger 61 andhigh pressure housing 111. As the weight is applied downward onelastomeric seal 105,seal 105 expands radially outward, sealing between runningtool 31 andhigh pressure housing 111. As thestem 33 andpiston 83 move further longitudinally downward relative toinner body 43, thelimit pin 89 captured inaperture 97 onpiston 83 also moves further longitudinally downward relative toinner body 43.Limit pin 89reaches test slot 71 and is forced radially inward byspring 95.Restrictor 75 preventslimit pin 89 from fully entering slot 71 (FIG. 7 ). As thestem 33 moves further longitudinally downward relative toinner body 43, theseal 49 on the inner surface ofinner body 43 and raisedprofiles stem 33 also move relative to one another.Seal 49 on the inner surface ofinner body 43 disengages from first raisedprofile 37 on the outer surface of stem 33 (FIG. 8 ). - Referring to
FIG. 9 , drillpipe rams (not shown) or an annular blower preventer (not shown) are closed and fluid pressure is applied down the annulus. Elastomeric seal 105 seals between runningtool 31 andhigh pressure housing 111, allowing the pressure aboveseal 105 to build until it forcesstem 33 andpiston 83 longitudinally downward relative toinner body 43. As thepiston 83 moves downward, the movement ofpiston 83 sets thepackoff seal 103 between an outer portion ofcasing hanger 61 and the inner diameter of thesubsea wellhead housing 111.Piston 83 moves longitudinally downward relative toinner body 43 until piston chamber 85 (FIG. 1 ) is eliminated andpiston 83 andinner body 43 are in contact with one another. As thestem 33 andpiston 83 move further longitudinally downward relative toinner body 43, thelimit pin 89 captured inaperture 97 onpiston 83 also moves further longitudinally downward relative toinner body 43. When thepiston 83 has moved longitudinally downward relative to the inner body sufficiently to setpackoff seal 103,limit pin 89 reaches the lower portion oftest slot 71 and is no longer restricted byrestrictor 75.Limit pin 89 is forced further radially inward byspring 95, fully enteringslot 71 and reaching a “set” position (FIG. 10 ). - Referring to
FIG. 11 , once thepiston 83 is driven downward andpackoff seal 103 is set, the drill string (not shown) and subsequently stem 33 andpiston 83 are pulled longitudinally upward relative toinner body 43 with sufficient force to releasepackoff seal 103 from settingsleeve 101. As thestem 33 andpiston 83 move longitudinally upward relative toinner body 43, the weight is removed fromelastomeric seal 105 and it moves radially inward, disengaging the inner surface of thewellhead housing 111, thereby permitting fluid flow past theseal 105. Aspiston 83 moves longitudinally upward relative toinner body 43,limit pin 89 travels upwards inslot 71 on theinner body 43 untillimit pin 89 reaches the uppermost end ofslot 71 reaching a “test” position (FIG. 12 ). As thestem 33 moves longitudinally upward relative toinner body 43, theseal 49 on the inner surface ofinner body 43 and raisedprofiles stem 33 also move relative to one another.Seal 49 engages the first raisedprofile 37 on the outer surface of stem 33 (FIG. 13 ). This position prohibits fluid communication from the exterior ofinner body 43 to the interior of theinner body 43, throughfluid port 51 andchamber 85. With thelimit pin 89 in the uppermost end oftest slot 71 on theinner body 43, fluid pressure is applied down the annulus to the upper side ofpackoff seal 103, thereby testing it. - Referring to
FIG. 14 , once thepackoff seal 103 has been tested, thestem 33 is then rotated four additional revolutions in the same direction. As thestem 33 is rotated relative to theinner body 43,cam 65 moves longitudinally downward relative toinner body 43. Ascam 65 moves longitudinally downward relative toinner body 43, engagingelement 57 is no longer forced outward bycam 65, and moves radially inward, thereby unlocking the runningtool 31 from thecasing hanger 61. Runningtool 31 may then be removed from the wellbore and returned to the surface. - Referring to
FIGS. 15 through 19 , ifpackoff seal 103 is not properly set, runningtool 31 prevents thepackoff 103 from being tested. For example, if debris and/ortrash 113 is present in the shoulder area ofhanger 61,seal 103 may not properly set. As illustrated inFIG. 15 , pressure has been applied aboveelastomeric seal 105 to setpackoff seal 103, however, stem 33 andpiston 83 did not move sufficiently longitudinally downward relative toinner body 43 to setpackoff seal 103. As illustrated inFIG. 17 , althoughlimit pin 89 has moved radially inward and partially enteredslot 71,restrictor 75 has preventedlimit pin 89 from fully enteringtest slot 71. Sincepiston 83 did not move sufficiently longitudinally downward relative toinner body 43 to setpackoff seal 103,limit pin 89 also did not move sufficiently longitudinally downward relative toinner body 43 to fully entertest slot 71. - Referring to
FIG. 17 , as discussed above, the running and testing sequence is continued and thestem 33 andpiston 83 are pulled longitudinally upward relative to theinner body 43 with sufficient force to release thepackoff seal 103 from the settingsleeve 101. As thestem 33 andpiston 83 move longitudinally upward relative toinner body 43, the weight is removed fromelastomeric seal 105 and it moves radially inward, disengaging the inner surface of thewellhead housing 111, thereby permitting fluid flow past theseal 105. Aspiston 83 moves longitudinally upward relative toinner body 43,limit pin 89 travels upwards inslot 71, restricted from moving radially inward by restrictor 75 on theinner body 43. Thelimit pin 89 reaches an upper end ofslot 71 where it contacts downward facingshoulder 89 which prevents further upward movement of limit pin 89 (FIG. 18 ). Because the limit pin did not fully enterslot 71,limit pin 89 can not reach the uppermost end of slot 71 (FIG. 12 ). This position is considered a “safe” position that will prevent atrue packoff seal 103 test. (FIG. 18 ). - As the
stem 33 moves longitudinally upward relative toinner body 43, theseal 49 on the inner surface ofinner body 43 and raisedprofiles stem 33 also move relative to one another. Because the limit pin did not fully enterslot 71, stem 33 andpiston 83 can not move sufficiently longitudinally upward relative toinner body 43 forseal 49 to engage the first raisedprofile 37 on the outer surface of stem 33 (FIG. 19 ). As a result, fluid may communicate from the exterior ofinner body 43 throughfluid port 51, intochamber 85, through the space between the interior of theinner body 43 andstem 33, and back up the drill string. - With the
limit pin 89 in the “safe” position, fluid pressure is applied down the annulus. However, before the pressure can build up on the upper side ofpackoff seal 103, the fluid travels throughfluid port 51 ininner body 43 and intochamber 85. The fluid then travels through the unsealed passage betweeninner body 43 and stem 33 before traveling through the remainder of runningtool 31 and back up the string of drill pipe. Returns on the surface end of the string of drill pipe (not shown) indicate that thelimit pin 89 is in the “safe” position, and the stroke ofpiston 83 was not sufficient to setpackoff seal 103. - The technique has significant advantages. The running tool combines the limit pin and the test slot with the raised profile portion of the stem and the seal on the inner body to ensure that the packoff is not pressure tested unless the proper setting stroke is made by the running tool. The fluid port allows fluid to travel from the exterior of the running tool through the components and back up the drill string if the packoff has not been properly set, reducing the chance of pressure leaking past the packoff and collapsing the casing.
- While the technique has been shown in only one of its forms, it should be apparent to those skilled in the art that it is not so limited but is susceptible to various changes without departing from the scope of the technique.
Claims (19)
1. A running tool for setting a packoff of a well pipe hanger, the running tool comprising:
an elongated stem having an axial passage;
an inner body substantially surrounding and connected to the stem such that rotation of the stem causes the stem to translate axially relative to the inner body;
a piston connected to the stem such that the piston and the stem rotate and translate in unison, the piston substantially surrounding portions of the stem and the inner body;
at least one slot positioned in and extending axially along a length of the outer surface of the inner body, the at least one slot extending radially inward through the outer surface of the inner body; and
at least one pin carried by the piston and adapted to move radially inward and engage the at least one slot when the piston moves axially relative to the inner body to a set position to thereby set a packoff.
2. The running tool according to claim 1 , wherein the running tool further comprises:
a raised profile on an exterior portion of the stem; and
a seal connected to the inner body and positioned between the stem and the inner body such that it sealingly engages the raised profile portion of the stem when the piston and stem move axially relative to the inner body to a test position to thereby pressure test the packoff.
3. The running tool of claim 2 , wherein the running tool further comprises:
a chamber defined by the outer peripheries of the exterior surface of the stem, the interior surface of the piston, and an upper surface of the inner body; and
a port extending from the outer surface of the inner body and into the chamber such that fluid can communicate from the exterior of the running tool through the port, into the chamber, and between the stem and inner body and back up the stem when the piston moves axially relative to the inner body to a safe position to thereby disengage the seal and the raised profile portion of the stem.
4. The running to tool of claim 1 , wherein the running tool further comprises:
threads on an inner portion of the inner body;
a cam positioned between the stem and the inner body, the cam connected to the stem such that the two rotate in unison but translate independent from one another, the cam having threads on its outer surface and a downward facing shoulder positioned adjacent thereto, the cam being threaded to the inner body; and
an engagement element, carried by the inner body and adapted to be engaged with a hanger, the axial movement of the stem relative to the inner body causing the shoulder to contact the engagement element and move it radially outward and in engagement with the hanger to releasably secure the running tool to the hanger.
5. The running tool according to claim 1 , wherein the slot has a greater width at a lower portion thereof than at an upper portion thereof to permit the pin to fully engage the slot when the piston moves axially relative to the inner body to the set position.
6. A method of setting and testing a packoff of a well pipe hanger, the method comprising:
(a) mounting a packoff to a running tool;
(b) running the tool and a well pipe hanger on a string of conduit into a subsea wellhead;
(c) applying fluid pressure to the annular area surrounding the string of conduit to set the packoff;
(d) moving the tool toward a test position and again applying fluid pressure to the annular area surrounding the string of conduit, and if the tool does not move to the test position, the fluid in the annular area surrounding the string of conduit is directed to flow up the conduit.
7. The method of claim 6 , the method further comprising:
providing the running tool with an elongated stem having an axial passage; an inner body substantially surrounding and connected to the stem such that rotation of the stem causes the stem to translate axially relative to the inner body; a piston substantially surrounding portions of the stem and the inner body and connected to the stem such that the two move in unison, the piston axially moveable relative to the inner body; a slot located in and extending through the inner body; and a pin connected to the piston; and
wherein the method further comprises after step (a) but before step (b):
rotating the stem relative to the inner body to a run-in position, thereby securely engaging the running tool with the well pipe hanger.
8. The method of claim 7 , wherein step (b) further comprises:
rotating the stem relative to the inner body to a pre-land position, thereby releasing the piston and the stem for axial movement relative to the inner body; and
lowering the stem and the piston axially relative to the inner body to a landing position.
9. The method of claim 7 , wherein step (c) further comprises:
moving the piston and the stem axially downward relative to the inner body and at least partially engaging the pin in the slot; and
wherein step (d) further comprises:
moving the piston and the stem axially upward relative to the inner body.
10. The method of claim 8 , wherein movement from the run-in position to the pre-land position is accomplished by rotating the stem in the same direction relative to the inner body.
11. The method of claim 8 , wherein the stem moves axially downward relative to the inner body when the stem is rotated form the run-in position to the pre-land position.
12. The method of claim 9 , the method further comprising:
providing the running tool with a raised profile on an exterior portion of the stem; a seal element on the inner surface of the inner body; a fluid port extending from an outer surface of the inner body to an upper surface thereof; and
wherein step (d) further comprises:
if the tool moves to the test position, engaging the seal element with the raised profile on the stem, thereby sealing between the inner body and the stem, preventing fluid from communicating from the annular area, through the fluid port, and back up the conduit.
13. A method of setting and testing a casing hanger packoff, the method comprising:
(a) providing a running tool with an elongated stem having an axial passage and a raised profile on its outer surface; an inner body surrounding and connected to the stem such that rotation of the stem causes the stem to translate axially relative to the inner body; a piston substantially surrounding portions of the stem and the inner body and connected to the stem such that the two move in unison, downwardly moveable relative to the inner body; a slot located in and extending through the inner body; a pin connected to the piston; a chamber defined by the outer boundaries of the exterior surface of the stem, the interior surface of the piston, and an upper surface of the inner body; a port located in the exterior surface of the inner body and extending through it and into the chamber; a seal element connected to the inner surface of the inner body; and
(b) rotating the stem relative to the inner body to a run-in position, thereby securely engaging the running tool with a hanger;
(c) running the tool and the hanger into a subsea wellhead;
(d) rotating the stem relative to the inner body to thereby release the stem and piston for axial movement relative to the inner body;
(e) lowering the stem and the piston axially relative to the inner body to a landing position;
(f) applying fluid pressure to an annular area surrounding the piston to further move the piston and stem axially downward relative to the inner body, thereby at least partially engaging the pin in the slot;
(g) raising the stem and piston axially relative to the inner body; and
(h) applying fluid pressure to the annular area above the packoff.
14. The method of claim 13 , further comprising:
providing a running tool with a raised profile on the outer surface of the stem; a chamber defined by the outer boundaries of the exterior surface of the stem, the interior surface of the piston, and an upper surface of the inner body; a fluid port located in the exterior surface of the inner body and extending through it and into the chamber; a seal element connected to the inner surface of the inner body; and
wherein step (f) further comprises:
fully engaging the pin in the slot, thereby moving the pin to a set position within the slot; and
wherein step (g) further comprises:
moving the pin to a test position within the slot; and
engaging the seal element with the raised profile on the stem, thereby sealing between the inner body and the stem, preventing fluid from communicating from the annular area, through the fluid port, and back up the axial passage; and
wherein step (h) further comprises:
testing the packoff.
15. The method of claim 13 , further comprising:
providing a running tool with a chamber defined by the outer boundaries of the exterior surface of the stem, the interior surface of the piston, and an upper surface of the inner body; a fluid port located in the exterior surface of the inner body and extending through it and into the chamber; and
wherein step (f) further comprises:
partially engaging the pin in the slot, thereby moving the pin to a safe position within the slot; and
wherein step (g) further comprises:
moving the pin upwards within the slot, maintaining the safe position; and
wherein step (h) further comprises:
communicating fluid pressure from the annular area, through the fluid port, and back up the axial passage, thereby preventing the packoff from being tested.
16. The method of claim 13 , further comprising after step (h):
rotating the stem relative to the inner body in the same direction to a release position, thereby releasing the running tool from the casing hanger.
17. A running tool for setting an annular seal having an energizing ring in a subsea well, the running tool comprising:
a member adapted to position the annular inner seal within the subsea well;
a piston adapted to drive the energizing ring to set the annular seal in the subsea well; and
a safety system adapted to prevent a test pressure from being applied to the annular seal after the annular seal has been set by the energizing ring unless the energizing ring is located at a desired position relative to the annular seal.
18. The running tool according to claim 17 , wherein the safety system is adapted to vent a region above the annular seal unless the energizing ring is located at the desired position relative to the annular seal.
19. The running tool according to claim 17 , wherein the safety system is adapted to prevent the piston from being moved to a test position that enables the test pressure to be applied to the annular seal unless the energizing ring is located at the desired position relative to the annular seal.
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/490,874 US8286711B2 (en) | 2009-06-24 | 2009-06-24 | Running tool that prevents seal test |
EP10165667A EP2282000A2 (en) | 2009-06-24 | 2010-06-11 | Running tool that prevents seal test |
MYPI2010002754A MY154131A (en) | 2009-06-24 | 2010-06-14 | Running tool that prevents seal test |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/490,874 US8286711B2 (en) | 2009-06-24 | 2009-06-24 | Running tool that prevents seal test |
Publications (2)
Publication Number | Publication Date |
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US20100326664A1 true US20100326664A1 (en) | 2010-12-30 |
US8286711B2 US8286711B2 (en) | 2012-10-16 |
Family
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Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US12/490,874 Expired - Fee Related US8286711B2 (en) | 2009-06-24 | 2009-06-24 | Running tool that prevents seal test |
Country Status (3)
Country | Link |
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US (1) | US8286711B2 (en) |
EP (1) | EP2282000A2 (en) |
MY (1) | MY154131A (en) |
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US20120037382A1 (en) * | 2010-08-13 | 2012-02-16 | Vetco Gray Inc. | Running Tool |
US20130319688A1 (en) * | 2012-05-31 | 2013-12-05 | Tesco Corporation | Rotating casing hanger |
US20150292315A1 (en) * | 2014-04-09 | 2015-10-15 | Vetco Gray Inc. | Multifunctional test tool for subsea applications |
US9376881B2 (en) | 2012-03-23 | 2016-06-28 | Vetco Gray Inc. | High-capacity single-trip lockdown bushing and a method to operate the same |
US9638005B2 (en) | 2013-06-12 | 2017-05-02 | Exxonmobil Upstream Research Company | Combined anti-rotation apparatus and pressure test tool |
US10077622B2 (en) | 2011-05-19 | 2018-09-18 | Vetco Gray, LLC | Tubing hanger setting confirmation system |
US10156121B2 (en) * | 2015-07-06 | 2018-12-18 | Cameron International Corporation | Testable backpressure valve system |
US11560767B1 (en) | 2021-07-20 | 2023-01-24 | Fmc Technologies, Inc. | Single run preloaded casing hanger and annulus seal assembly and methods of use thereof |
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EP2690250A1 (en) * | 2010-02-17 | 2014-01-29 | Cameron International Corporation | Running tool with independent housing rotation sleeve |
WO2011109074A1 (en) * | 2010-03-02 | 2011-09-09 | Fmc Technologies, Inc. | Riserless single trip hanger and packoff running tool |
GB2517784A (en) * | 2013-09-02 | 2015-03-04 | Plexus Holdings Plc | Running tool |
US10077620B2 (en) * | 2014-09-26 | 2018-09-18 | Cameron International Corporation | Load shoulder system |
US10934800B2 (en) | 2019-07-31 | 2021-03-02 | Weatherford Technology Holdings, Llc | Rotating hanger running tool |
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US8408309B2 (en) * | 2010-08-13 | 2013-04-02 | Vetco Gray Inc. | Running tool |
US20120037382A1 (en) * | 2010-08-13 | 2012-02-16 | Vetco Gray Inc. | Running Tool |
US10689936B2 (en) | 2011-05-19 | 2020-06-23 | Vetco Gray, LLC | Tubing hanger setting confirmation system |
US10711554B2 (en) | 2011-05-19 | 2020-07-14 | Vetco Gray Inc. | Tubing hanger setting confirmation system |
US10077622B2 (en) | 2011-05-19 | 2018-09-18 | Vetco Gray, LLC | Tubing hanger setting confirmation system |
US9376881B2 (en) | 2012-03-23 | 2016-06-28 | Vetco Gray Inc. | High-capacity single-trip lockdown bushing and a method to operate the same |
US20130319688A1 (en) * | 2012-05-31 | 2013-12-05 | Tesco Corporation | Rotating casing hanger |
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WO2015156910A1 (en) * | 2014-04-09 | 2015-10-15 | Vetco Gray Inc. | Multifunctional test tool for subsea applications |
US10156121B2 (en) * | 2015-07-06 | 2018-12-18 | Cameron International Corporation | Testable backpressure valve system |
US11560767B1 (en) | 2021-07-20 | 2023-01-24 | Fmc Technologies, Inc. | Single run preloaded casing hanger and annulus seal assembly and methods of use thereof |
WO2023003896A1 (en) * | 2021-07-20 | 2023-01-26 | Fmc Technologies, Inc. | Single run preloaded casing hanger and annulus seal assembly and methods of use thereof |
Also Published As
Publication number | Publication date |
---|---|
US8286711B2 (en) | 2012-10-16 |
EP2282000A2 (en) | 2011-02-09 |
MY154131A (en) | 2015-05-15 |
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Legal Events
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Owner name: VETCO GRAY INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:NETO, GUILHERME PEDRO EPPINGHAUS, MR.;KOBATA, FRANCISCO, MR.;GETTE, NICHOLAS P., MR.;REEL/FRAME:022870/0527 Effective date: 20090623 |
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Free format text: PATENT EXPIRED DUE TO NONPAYMENT OF MAINTENANCE FEES UNDER 37 CFR 1.362 |
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Effective date: 20161016 |